WO2014205224A2 - Systèmes et procédés pour le fonctionnement amélioré de colonnes dans des environnements offshore - Google Patents

Systèmes et procédés pour le fonctionnement amélioré de colonnes dans des environnements offshore Download PDF

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Publication number
WO2014205224A2
WO2014205224A2 PCT/US2014/043193 US2014043193W WO2014205224A2 WO 2014205224 A2 WO2014205224 A2 WO 2014205224A2 US 2014043193 W US2014043193 W US 2014043193W WO 2014205224 A2 WO2014205224 A2 WO 2014205224A2
Authority
WO
WIPO (PCT)
Prior art keywords
output line
static mixer
input opening
fluid communication
separator
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/US2014/043193
Other languages
English (en)
Other versions
WO2014205224A3 (fr
Inventor
Guang-Chung Lee
Sudhir Golikeri
Jie Yu
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Bechtel Energy Technologies and Solutions Inc
Original Assignee
Bechtel Hydrocarbon Technology Solutions Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Bechtel Hydrocarbon Technology Solutions Inc filed Critical Bechtel Hydrocarbon Technology Solutions Inc
Priority to US14/900,030 priority Critical patent/US10456740B2/en
Priority to CA2914850A priority patent/CA2914850C/fr
Publication of WO2014205224A2 publication Critical patent/WO2014205224A2/fr
Publication of WO2014205224A3 publication Critical patent/WO2014205224A3/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B01D53/18—Absorbing units; Liquid distributors therefor
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D19/00—Degasification of liquids
    • B01D19/0005—Degasification of liquids with one or more auxiliary substances
    • B01D19/001—Degasification of liquids with one or more auxiliary substances by bubbling steam through the liquid
    • B01D19/0015—Degasification of liquids with one or more auxiliary substances by bubbling steam through the liquid in contact columns containing plates, grids or other filling elements
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D3/00—Distillation or related exchange processes in which liquids are contacted with gaseous media, e.g. stripping
    • B01D3/14—Fractional distillation or use of a fractionation or rectification column
    • B01D3/32—Other features of fractionating columns ; Constructional details of fractionating columns not provided for in groups B01D3/16 - B01D3/30
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D3/00—Distillation or related exchange processes in which liquids are contacted with gaseous media, e.g. stripping
    • B01D3/42—Regulation; Control
    • B01D3/4205—Reflux ratio control splitter
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B01D53/1425—Regeneration of liquid absorbents
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B01D53/1456—Removing acid components
    • B01D53/1462—Removing mixtures of hydrogen sulfide and carbon dioxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B01D53/1456—Removing acid components
    • B01D53/1475—Removing carbon dioxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B35/00—Vessels or similar floating structures specially adapted for specific purposes and not otherwise provided for
    • B63B35/44—Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/20—Organic absorbents
    • B01D2252/204—Amines
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/50—Carbon oxides
    • B01D2257/504—Carbon dioxide
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
    • Y02C20/00—Capture or disposal of greenhouse gases
    • Y02C20/40—Capture or disposal of greenhouse gases of CO2

Definitions

  • the present disclosure generally relates to systems and methods for improved column operation in offshore environments. More particularly, the present disclosure relates to improved column operation in offshore environments by using a co-current contactor system in floating production, storage and offloading (FPSO) systems.
  • FPSO floating production, storage and offloading
  • Offshore processing of natural gas or oil associated gas is becoming a more and more attractive alternative to conventional land-based facilities.
  • Marginal gas fields can be economically developed by means of the FPSO concept.
  • Offshore processing plants on floating structures can be production units for liquefied natural gas (LNG), liquefied petroleum gas (LPG), methanol, gas to liquid (GTL), or ammonia.
  • LNG liquefied natural gas
  • LPG liquefied petroleum gas
  • GTL gas to liquid
  • ammonia The ability to station the FPSO vessel directly over fields avoids expensive offshore pipelines.
  • the production facility can be moved to a new location to continue production.
  • the present disclosure overcomes one or more deficiencies in the prior art by providing systems and methods for improved column operation in offshore environments by using a co-current contactor system in floating production, storage and offloading (FPSO) systems.
  • FPSO floating production, storage and offloading
  • the present disclosure includes co-current contact system for operating an absorption column in offshore environments, which comprises: i) a solvent regeneration unit having a rich amine input opening in fluid communication with a rich amine output line connected to the absorption column and a lean amine output line in fluid communication with a lean amine input opening in the absorption column; a static mixer having a static mixer input opening in fluid communication with the lean amine output line, a treated gas input opening in fluid communication with a treated gas output line connected to the absorption column and a static mixer output line; and iii) a separator having a separator input opening in fluid communication with the static mixer output line, a separator liquid output line and a separator vapor output line.
  • the present disclosure includes a co-current contact system for operating a distillation column in offshore environments, which comprises: i) a static mixer having a first static mixer input opening in fluid communication with a reflux pump output line connected to a reflux pump, a second static mixer input opening in fluid communication with a distillation column output line connected to the distillation column and a static mixer output line in fluid communication with a condenser input opening in a condenser; and ii) a reflux drum having a reflux drum input opening in fluid communication with a condenser output line connected to the condenser, a first reflux drum output line in fluid communication with a reflux pump input opening in the reflux pump and a second reflux drum output line.
  • the present disclosure includes a method for operating an absorption column in offshore environments using a co-current contact system, which comprises: i) sending lean amine from a solvent regeneration unit to the co-current contact system, wherein the co-current contact system comprises a static mixer and a separator; ii) mixing the lean amine and a treated gas from the absorption column in the static mixer; and iii) separating the mixed lean amine and treated gas into a vapor and a liquid using the separator.
  • the present disclosure includes a method for operating a distillation column in offshore environments using a co-current contact system, which comprises: i) sending a reflux liquid from a reflux drum to the con-concurrent contact system, wherein the co-current contact system comprises a static mixer and a condenser; ii) mixing the reflux liquid and a vapor from the distillation column in the static mixer; and iii) condensing the mixed reflux liquid and vapor into a mixed condensate using the condenser.
  • FIG. 1 is a schematic diagram illustrating one embodiment of a co-current contact system for use in a conventional acid gas removal system according to the present disclosure.
  • FIG. 2 is schematic diagram illustrating another embodiment of a co-currrent contact system for use in a conventional acid gas removal system according to the present disclosure.
  • FIG. 3 is a schematic diagram illustrating yet another embodiment of a co- currrent contact system for use in a conventional acid gas removal system according to the present disclosure.
  • FIG. 4 is a schematic diagram illustrating yet another embodiment of a co- currrent contact system for use in a conventional acid gas removal system according to the present disclosure.
  • FIG. 5 is a schematic diagram illustrating another embodiment of a co-current contact system that may be used in place of the co-current contact system illustrated in FIGS. 1- 4.
  • FIG. 6 is a schematic diagram illustrating yet another embodiment of a co-current contact system that may be used in place of the co-current contact system illustrated in FIGS. 1-
  • FIG. 7 is a schematic diagram illustrating one embodiment of a co-current contact system for use with a distillation column according to the present disclosure.
  • FIGS. 1-7 includes systems and methods for improved column operation in offshore environments using co-current contactor systems to improve mixing between incoming streams.
  • various embodiments of a co-current contact system are illustrated in an exemplary acid gas removal system or with an exemplary distillation column.
  • the co-current contact system includes a static mixer insensitive to motion, which provides mixing between the incoming streams.
  • a static mixer may include, for example, of a series of motionless elements installed in a pipe. These elements promote mixing of two or more fluids, which flow through the pipe due to a pressure gradient. Where needed, multiple stages of such mixing can be utilized.
  • the co-current contactor system When used with an absorption column, the co-current contactor system is positioned downstream of the absorption column to treat the vapor leaving the absorption column overhead. When used with a distillation column, the co-current contactor system is positioned downstream of the distillation column before the condenser.
  • FIG. 1 a schematic diagram illustrates one embodiment of a co- current contact system for use in a conventional acid gas removal system.
  • the acid gas removal system includes an absorber 106 and a solvent regeneration unit 130.
  • the co-current contact system includes a static mixer 112 and a separator 120.
  • the absorber 106 has an input opening 104 located below the lower packed section adapted for fluid communication with a feed gas line 102.
  • the solvent regeneration unit 130 has a rich amine input opening 132 in fluid communication with a rich amine output line 128 at the bottom of the absorber 106 and a lean amine output line 134 in fluid communication with a lean amine input opening 108 near the top of the absorber 106.
  • the static mixer 112 has a static mixer input opening 116 in fluid communication with the lean amine output line 134, a treated gas input opening 114 in fluid communication with a treated gas output line 110 from the top of the absorber 106, and a static mixer output line 118.
  • the treated gas output line 110 is generally specified to contain less than 50ppm C0 2 and less than 5mg Nm 3 H 2 S.
  • the separator 120 has a separator input opening 122 in fluid communication with the static mixer output line 118, a separator liquid output line 124, and a separator vapor output line 126.
  • FIG. 2 a schematic diagram illustrates another embodiment of a co-currrent contact system for use in a conventional acid gas removal system.
  • the acid gas removal system includes an absorber 106 and a solvent regeneration unit 130.
  • the co-current contact system includes a static mixer 112 and a separator 120.
  • the absorber 106 has an input opening 104 located below the lower packed section adapted for fluid communication with a feed gas line 102.
  • the solvent regeneration unit 130 has a rich amine input opening 132 in fluid communication with a rich amine output line 128 at the bottom of the absorber 106 and a lean amine output line 134 in fluid communication with a lean amine input opening 108 near the top of the absorber 106.
  • the static mixer 112 has a static mixer input opening 116 in fluid communication with the lean amine output line 134, a treated gas input opening 114 in fluid communication with a treated gas output line 110 from the top of the absorber 106, and a static mixer output line 118.
  • the treated gas output line 110 is generally specified to contain less than 50ppm C0 2 and less than 5mg/Nm 3 H 2 S.
  • the separator 120 has a separator input opening 122 in fluid communication with the static mixer output line 118, a separator liquid output line 124, and a separator vapor output line 126.
  • a sufficient amount of lean amine from the lean amine output line 134 is sent to the static mixer 112 through the static mixer input opening 116 where it is mixed with the gas from the treated gas output line 110 as it enters the static mixer 112 through the treated gas input opening 114.
  • the resulting treated gas from the separator vapor output line 126 will meet acid gas specifications and semi-lean amine from the separator liquid output line 124 is combined with the lean amine from the lean amine output line 134 before entering the absorber 106 through the lean amine input opening 108.
  • the acid gas removal system includes an absorber 106 and a solvent regeneration unit 130.
  • the co-current contact system includes a static mixer 112 and a separator 120.
  • the absorber 106 has an input opening 104 located below the lower packed section adapted for fluid communication with a feed gas line 102.
  • the solvent regeneration unit 130 has a rich amine input opening 132 in fluid communication with a rich amine output line 128 at the bottom of the absorber 106 and a lean amine output line 134 in fluid communication with a lean amine input opening 108 near the top of the absorber 106.
  • the static mixer 112 has a static mixer input opening 116 in fluid communication with the lean amine output line 134, a treated gas input opening 114 in fluid communication with a treated gas output line 110 from the top of the absorber 106, and a static mixer output line 118.
  • the treated gas output line 110 is generally specified to contain less than 50ppm C0 2 and less than 5mg/Nm 3 H 2 S.
  • the separator 120 has a separator input opening 122 in fluid communication with the static mixer output line 118, a separator liquid output line 124, and a separator vapor output line 126.
  • a sufficient amount of lean amine from the lean amine output line 134 is sent to the static mixer 112 through the static mixer input opening 116 where it is mixed with the gas from the treated gas output line 110 as it enters the static mixer 112 through the treated gas input opening 114.
  • the resulting treated gas from the separator vapor output line 126 will meet acid gas specifications and semi-lean amine from the separator liquid output line 124 is sent to the absorber 106 through another lean amine input opening 304. In this manner, the semi-lean amine will not dilute the lean amine from the lean amine output line 134.
  • FIG. 4 a schematic diagram illustrates yet another embodiment of a co-currrent contact system for use in a conventional acid gas removal system.
  • the acid gas removal system includes an absorber 106 and a solvent regeneration unit 130.
  • the co-current contact system includes a static mixer 112 and a separator 120.
  • the absorber 106 has an input opening 104 located below the lower packed section adapted for fluid communication with a feed gas line 102.
  • the solvent regeneration unit 130 has a rich amine input opening 132 in fluid communication with a rich amine output line 128 at the bottom of the absorber 106 and a lean amine output line 134 in fluid communication with a lean amine input opening 108 near the top of the absorber 106.
  • the static mixer 112 has a static mixer input opening 116 in fluid communication with the lean amine output line 134, a treated gas input opening 114 in fluid communication with a treated gas output line 110 from the top of the absorber 106, and a static mixer output line 118.
  • the treated gas output line 110 is generally specified to contain less than 50ppm C0 2 and less than 5mg Nm 3 H 2 S.
  • the separator 120 has a separator input opening 122 in fluid communication with the static mixer output line 118, a separator liquid output line 124, and a separator vapor output line 126.
  • a sufficient amount of lean amine from the lean amine output line 134 is sent to the static mixer 112 through the static mixer input opening 116 where it is mixed with the gas from the treated gas output line 110 as it enters the static mixer 112 through the treated gas input opening 114.
  • the resulting treated gas from the separator vapor output line 126 will meet acid gas specifications and semi-lean amine from the separator liquid output line 124 is sent to the solvent regenerator unit 130 through a semi-lean amine input opening 404.
  • FIG. 5 a schematic diagram illustrates another embodiment of a co-current contact system that may be used in place of the co-current contact system illustrated in FIGS. 1-4.
  • the co-current contact system includes another static mixer 504 and another separator 512.
  • the another static mixer 504 has another static mixer input opening 506 in fluid communication with the separator vapor output line 126 for carrying treated gas, a lean amine input opening 508 in fluid communication with the lean amine output line 134, and another static mixer output line 510.
  • the another separator 512 has another separator input opening 514 in fluid communication with the another static mixer output line 510, another separator liquid output line 516 for carrying semi-lean amine, and another separator vapor output line 518 for carrying twice treated gas.
  • feed gas from the treated gas input opening 114 is mixed in the static mixer 112 with lean amine from the static mixer input opening 116.
  • Treated gas from the separator 120 is further mixed in the another static mixer 504 with lean amine from the lean amine input opening 508.
  • the treated gas from the another static mixer 504 will meet acid gas specifications and the semi-lean amine from the another separator liquid output line 516 and the separator liquid output line 124 is sent to the absorber 106.
  • FIG. 6 a schematic diagram illustrates yet another embodiment of a co-current contact system that may be used in place of the co-current contact system illustrated in FIGS. 1-4.
  • the co-current contact system includes another static mixer 504 and another separator 512.
  • the another static mixer 504 has another static mixer input opening 506 in fluid communication with the separator vapor output line 126 for carrying treated gas, a lean amine input opening 508 in fluid communication with the lean amine output line 134, and another static mixer output line 510.
  • the another separator 512 has another separator input opening 514 in fluid communication with the another static mixer output line 510, another separator liquid output line 516 for carrying semi-lean amine, and another separator vapor output line 518 for carrying twice treated gas.
  • feed gas from the treated gas input opening 114 is mixed in the static mixer 112 with semi-lean amine from the another separator output line 516.
  • Treated gas from the separator 120 is further mixed in the another static mixer 504 with lean amine from the lean amine input opening 508.
  • the treated gas from the another static mixer 504 will meet acid gas specifications and the semi-lean amine from the another separator liquid output line 516 is sent to the first static mixer 112.
  • the semi-lean amine from the separator 120 is more enriched with C0 2 than the semi-lean amine from the another separator 512. In this manner, the total required lean amine flow rate is reduced compared to the embodiment described in reference to FIG. 5.
  • FIG. 7 is a schematic diagram illustrates another embodiment of a co-current contact system for use with a distillation column.
  • the co-current contact system includes a static mixer 706, a condenser 714, a reflux drum 720, and a reflux pump 730.
  • the distillation column 704 has a distillation column output line 705 and a distillation column input opening 734.
  • the static mixer 706 has a first static mixer input opening 708 in fluid communication with a reflux pump liquid output line 732, a second static mixer input opening 710 in fluid communication with the distillation column output line 705 and a static mixer output line 712 in fluid communication with a condenser input opening 716.
  • the reflux drum 720 has a reflux drum input opening 722 in fluid communication with a condenser output line 718, a first reflux drum output line 724 in fluid communication with a reflux pump input opening 728 on the reflux pump 730, and a second reflux drum output vapor line 726.
  • the reflux pump liquid output line 732 is in fluid communication with the distillation column input opening 734 and the static mixer input opening 708. In this embodiment, a portion of the reflux in the reflux pump liquid output line 732 is split and mixed with vapor from the distillation column output line 705 in the static mixer 706. In this manner, the overall separation is enhanced and multiple stages of such mixing, as illustrated in FIGS. 5-6, may be added.
  • any of the foregoing co-current contact systems may be further modified as illustrated in FIGS. 5 and 6.
  • the various embodiments of the co-current contact system illustrated in FIGS. 1-7 may be applied in a new system or may be used in preexisting systems with conventional absorption and/or distillation columns.

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  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Engineering & Computer Science (AREA)
  • Analytical Chemistry (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • General Chemical & Material Sciences (AREA)
  • Architecture (AREA)
  • Mechanical Engineering (AREA)
  • Ocean & Marine Engineering (AREA)
  • Combustion & Propulsion (AREA)
  • Structural Engineering (AREA)
  • Civil Engineering (AREA)
  • Gas Separation By Absorption (AREA)
  • Particle Accelerators (AREA)

Abstract

L'invention concerne des systèmes et des procédés pour le fonctionnement amélioré de colonnes dans des environnements offshore par utilisation d'un système contacteur co-courant dans des unités flottantes de production, stockage et déchargement en mer (FPSO).
PCT/US2014/043193 2013-06-19 2014-06-19 Systèmes et procédés pour le fonctionnement amélioré de colonnes dans des environnements offshore Ceased WO2014205224A2 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
US14/900,030 US10456740B2 (en) 2013-06-19 2014-06-19 Systems and methods for improved column operation in offshore environments
CA2914850A CA2914850C (fr) 2013-06-19 2014-06-19 Systemes et procedes pour le fonctionnement ameliore de colonnes dans des environnements offshore

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201361837169P 2013-06-19 2013-06-19
US61/837,169 2013-06-19

Publications (2)

Publication Number Publication Date
WO2014205224A2 true WO2014205224A2 (fr) 2014-12-24
WO2014205224A3 WO2014205224A3 (fr) 2015-02-26

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US (1) US10456740B2 (fr)
CA (1) CA2914850C (fr)
WO (1) WO2014205224A2 (fr)

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AR096132A1 (es) 2013-05-09 2015-12-09 Exxonmobil Upstream Res Co Separar dióxido de carbono y sulfuro de hidrógeno de un flujo de gas natural con sistemas de co-corriente en contacto
EP3242737A2 (fr) 2015-01-09 2017-11-15 Exxonmobil Upstream Research Company Séparation des impuretés d'un flux fluidique au moyen de plusieurs contacteurs à co-courant
AU2016220515B2 (en) 2015-02-17 2019-02-28 Exxonmobil Upstream Research Company Inner surface features for co-current contactors
CA2978899C (fr) 2015-03-13 2019-09-17 Exxonmobil Upstream Research Company Coalesceur destine a des contacteurs a co-courant
CA3067338C (fr) 2017-06-15 2023-03-07 Exxonmobil Upstream Research Company Systeme de fractionnement utilisant des systemes groupeurs compacts de mise en contact de co-courants
JP7015850B2 (ja) 2017-06-15 2022-02-03 エクソンモービル アップストリーム リサーチ カンパニー コンパクト並流接触システムを使用する分別システム
MX394342B (es) 2017-06-20 2025-03-24 Exxonmobil Upstream Res Co Sistemas de contacto compactos y metodos para depurar compuestos que contienen azufre.
MY202923A (en) 2017-08-21 2024-05-29 Exxonmobil Upstream Res Co Integration of cold solvent and acid gas removal
CN109276975A (zh) * 2018-10-22 2019-01-29 陆沈杰 一种节能环保的工业废气处理装置
CN115193085B (zh) * 2022-06-24 2024-04-12 金宏气体股份有限公司 一种用于生产正硅酸乙酯的精馏塔的塔顶压力和温度控制系统和方法
US20250242298A1 (en) * 2024-01-31 2025-07-31 Nuovo Pignone Tecnologie S.r.l. System and method of phase separation for absorption column

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US6071484A (en) 1997-01-24 2000-06-06 Mpr Services, Inc. Process for treating gas with ultra-lean amine
JP2012505747A (ja) * 2008-10-14 2012-03-08 エクソンモービル アップストリーム リサーチ カンパニー ガス流からの酸性ガスの除去
FR2947185B1 (fr) * 2009-06-26 2011-07-01 Total Sa Procede de traitement de gaz acides
US20110110833A1 (en) * 2009-11-12 2011-05-12 Chevron U.S.A. Inc. Method and apparatus for removing acid gases from a natural gas stream
US8899557B2 (en) * 2011-03-16 2014-12-02 Exxonmobil Upstream Research Company In-line device for gas-liquid contacting, and gas processing facility employing co-current contactors

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Publication number Publication date
CA2914850A1 (fr) 2014-12-24
WO2014205224A3 (fr) 2015-02-26
US20160136569A1 (en) 2016-05-19
CA2914850C (fr) 2019-01-15
US10456740B2 (en) 2019-10-29

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